US4785622A - Integrated coal gasification plant and combined cycle system with air bleed and steam injection - Google Patents

Integrated coal gasification plant and combined cycle system with air bleed and steam injection Download PDF

Info

Publication number
US4785622A
US4785622A US06/854,370 US85437086A US4785622A US 4785622 A US4785622 A US 4785622A US 85437086 A US85437086 A US 85437086A US 4785622 A US4785622 A US 4785622A
Authority
US
United States
Prior art keywords
steam
plant
turbine
gas turbine
gas
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Expired - Lifetime
Application number
US06/854,370
Inventor
Donald R. Plumley
Ashok K. Anand
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
General Electric Co
Original Assignee
General Electric Co
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Priority to US67737584A priority Critical
Application filed by General Electric Co filed Critical General Electric Co
Priority to US06/854,370 priority patent/US4785622A/en
Application granted granted Critical
Publication of US4785622A publication Critical patent/US4785622A/en
Anticipated expiration legal-status Critical
Application status is Expired - Lifetime legal-status Critical

Links

Images

Classifications

    • FMECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F02COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
    • F02CGAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
    • F02C3/00Gas-turbine plants characterised by the use of combustion products as the working fluid
    • F02C3/20Gas-turbine plants characterised by the use of combustion products as the working fluid using a special fuel, oxidant, or dilution fluid to generate the combustion products
    • F02C3/30Adding water, steam or other fluids for influencing combustion, e.g. to obtain cleaner exhaust gases
    • FMECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01KSTEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
    • F01K21/00Steam engine plants not otherwise provided for
    • F01K21/04Steam engine plants not otherwise provided for using mixtures of steam and gas; Plants generating or heating steam by bringing water or steam into direct contact with hot gas
    • F01K21/042Steam engine plants not otherwise provided for using mixtures of steam and gas; Plants generating or heating steam by bringing water or steam into direct contact with hot gas pure steam being expanded in a motor somewhere in the plant
    • FMECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01KSTEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
    • F01K23/00Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids
    • F01K23/02Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled
    • F01K23/06Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle
    • F01K23/067Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle the combustion heat coming from a gasification or pyrolysis process, e.g. coal gasification
    • F01K23/068Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle the combustion heat coming from a gasification or pyrolysis process, e.g. coal gasification in combination with an oxygen producing plant, e.g. an air separation plant
    • FMECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F02COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
    • F02CGAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
    • F02C7/00Features, components parts, details or accessories, not provided for in, or of interest apart form groups F02C1/00 - F02C6/00; Air intakes for jet-propulsion plants
    • F02C7/22Fuel supply systems
    • F02C7/224Heating fuel before feeding to the burner
    • YGENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02EREDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E20/00Combustion technologies with mitigation potential
    • Y02E20/10Combined combustion
    • Y02E20/16Combined cycle power plant [CCPP], or combined cycle gas turbine [CCGT]
    • YGENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02EREDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E20/00Combustion technologies with mitigation potential
    • Y02E20/10Combined combustion
    • Y02E20/16Combined cycle power plant [CCPP], or combined cycle gas turbine [CCGT]
    • Y02E20/18Integrated gasification combined cycle [IGCC]

Abstract

An integrated coal gasification plant and combined cycle system employs a supply of compressed air bled off at an intermediate pressure from an air compressor portion of a gas turbine to supply the compressed-air needs of an oxygen plant associated with the coal gasification plant. The high-temperature exhaust from the turbine section of the gas turbine is employed to generate steam in a heat recovery steam generator. The steam drives a steam turbine to produce additional mechanical output. In order to compensate for the removal of the compressed air fed to the oxygen plant, the spent steam from the steam turbine is added to the compressed air and fuel in the combustor portion of the gas turbine. The unexpended energy in the steam fed to the combustor is recovered by expansion in the turbine of the gas turbine and by absorption in the heat receovery stem generator. The release of steam through the gas turbine, and other disclosed techniques, permits elimination of the capital cost of a condenser and cooling tower which would otherwise be required. In addition, the direct provision of compressed air to the oxygen plant eliminates the capital and operating cost of the separate compressor and electric motor conventionally required to provide such compressed air.

Description

This application is a continuation of application Ser. No. 677,375 filed Dec. 3, 1984 now abandoned.

BACKGROUND OF THE INVENTION

The present invention relates to energy conversion devices and, more particularly, to a combined cycle gas and steam turbine system integrated with a coal gasification plant.

Gas turbines are frequently employed in, for example, electric generating installations, in order to take advantage of their rapid start-up and shutdown capabilities. For example, a gas turbine may be brought up from an inactive condition to full operation, as well as from full operation to a shut-down condition, in a matter of minutes. The simplicity afforded by this rapid start-up and shut-down capability is in contrast to the relatively slow and complex start-up and shut-down of large base-load steam turbines which are more economically maintained in operation for long periods measured, for example, in years. Although flexible in their ability to be started and stopped, gas turbines suffer thermodynamic inefficiency due to the relatively large part of the heat generated by fuel burning therein passing out unused in the exhaust therefrom. An exhaust temperature of, for example, 1030 degrees F. is conventional for a commercial gas turbine. Under normal conditions, a gas turbine generator has a thermodynamic efficiency of about 31 percent. In contrast, the thermodynamic efficiency of a base-load steam turbine power plant is on the order of about 38 percent. This difference in efficiency dictates that a gas turbine used in generating electricity in an electric network be customarily used for relatively short times, principally as a relatively high-cost peaking generation element which is started up only when the base-load apparatus is unable to sustain the system energy usage, and is shutdown as soon as the peak energy usage has passed.

Combined cycle systems include means for recovering the sensible heat available in the gas turbine exhaust for further use. One combined cycle system employs a heat recovery steam generator using gas turbine exhaust heat to generate steam which is then available to a using process such as, for example, a steam turbine. A combined cycle system using a heat recovery steam generator having a high pressure steam turbine followed by an intermediate pressure steam turbine is capable of a thermodynamic efficiency of about 46 percent.

Gas turbines require a clean fuel such as, for example, a liquid gaseous hydrocarbon. Both liquid and gaseous hydrocarbons are expected to become more scarce and expensive. A large quantity of coal is available but, due to the presence of unburned carbon, ash and other contaminants generated during direct use, coal is unsatisfactory for direct use in a gas turbine. Coal gasification may be employed to convert a substantial portion of the hydrocarbon in coal into a clean low-energy or medium-energy gaseous fuel suitable for use in a gas turbine. A preferred coal gasification process employs an oxygen plant to produce pure oxygen. The use of oxygen instead of air in the coal gas plant avoids the presence of nitrogen in the coal gas. Such nitrogen would not only reduce the heating value of the coal gas, but also may contribute to the generation of NOx emissions. After cleaning to remove particulate and chemical pollutants (principally sulfur), the coal gas is burned in the gas turbine.

A coal gasification plant may be integrated with a combined cycle system to produce an integrated plant in which the fuel gas produced by the coal gasification plant is fed directly to the combined cycle system for immediate consumption, or is stored for later consumption. Immediate consumption permits taking advantage of certain sources of thermodynamic efficiency such as, for example, the use of some of the waste heat energy of the coal gasification process to at least partly preheat the fuel gas fed to the gas turbine.

It will be clear to one skilled in the art, the improvement in thermodynamic efficiency obtained in a combined cycle system comes at the expense of increased capital cost. Substantial elements of cost in a combined cycle system are the condenser and a cooling tower which are conventionally required for condensing the spent steam from the steam turbine. Although a non-condensing steam cycle may be used, such a cycle is conventionally relatively inefficient since it requires venting a substantial portion of the spent steam from the steam turbine in order to permit recycling the remaining water in the spent steam. Venting steam wastes a substantial quantity of unused heat with it which may effect a substantial reduction in thermodynamic efficiency.

OBJECTS AND SUMMARY OF THE INVENTION

Accordingly, it is an object of the invention to provide an integrated gas plant and combined cycle system which overcomes the drawbacks of the prior art.

It is a further object of the invention to provide an integrated system in which a non-condensing steam system is employed to inject a portion of its spent steam from a high pressure steam turbine into a turbine portion of a gas turbine. The total mass flow rate through the turbine portion of the gas turbine is adjusted to a design value by bleeding off a portion of the compressed air from an intermediate stage of the compressor portion of the gas turbine. This permits the use of a standard gas turbine design, without requiring redesign, to accommodate a greater mass flow rate in the turbine portion. The steam exiting the high pressure steam turbine and fed to the gas turbine is at a pressure corresponding to the pressure of steam fed to conventional intermediate pressure turbine. The energy remaining in this intermediate-pressure steam is captured through expansion in the gas turbine thereby permitting omission of an intermediate pressure turbine.

It is a further object of the invention to provide an integrated gas plant and combined cycle system which eliminate the need for a condenser and cooling tower.

It is a further object of the invention to provide an integrated gas plant and combined cycle system which has increased efficiency at reduced capital cost, especially in power plants in the range of from about 50 to about 100 megawatts of electrical output.

It is a further object of the invention to provide an integrated gas plant and combined cycle system which employs a single section stream turbine which vents its spent steam to the combustor of a gas turbine.

It is a further object of the invention to provide an integrated gas plant and combined cycle system which vents intermediate pressure steam from a single-stage steam turbine into a combustor of a gas turbine. The injected steam reduces the NOx emissions of the gas turbine and expands in the turbine portion of the gas turbine to produce additional output energy. The heat remaining in the mixture of steam, as well as products of combustion and excess air exiting the gas turbine, is recovered in a heat recovery steam generator.

It is a further object of the invention to provide an integrated gas plant and combined cycle system in which compressed air for an oxygen plant is obtained by bleeding off air at an intermediate stage of the air compressor of the gas turbine while compensating for the reduced mass flow occasioned by the reduction in compressed air passing to the turbine portion of the gas turbine by injecting a portion of the steam generated in the heat recovery steam generator portion of the combined cycle system into the turbine portion.

Briefly stated, the present invention provides an integrated coal gasification plant and combined cycle system in which a supply of compressed air, bled off at an intermediate pressure from an air compressor portion of a gas turbine, supplies the compressed-air needs of an oxygen plant associated with the coal gasification plant. The high-temperature exhaust from the turbine section of the gas turbine is employed to generate steam in a heat recovery steam generator. The steam drives a steam turbine to produce additional mechanical output. In order to compensate for the removal of the compressed air fed to the oxygen plant, the spent steam from the steam turbine is added to the compressed air and fuel in the combustor portion of the gas turbine. The unexpended energy in the steam fed to the combustor is recovered by expansion in the turbine portion of the gas turbine and by absorption in the heat recovery steam generator. The release of steam through the gas turbine, and other disclosed techniques, permits the use of a non-condensing system and thus permits elimination of the capital cost of a condenser and cooling tower which would otherwise be required. In addition, the direct provision of compressed air to the oxygen plant eliminates the capital and operating costs of the separate compressor and electric motor conventionally required to provide such compressed air.

According to an embodiment of the invention, there is provided an integrated combined cycle system comprising a coal gas plant effective for producing a supply of a gaseous fuel, a gas turbine of a type including an air compressor, a combustor and a turbine, the air compressor being of a type effective to produce a first supply of compressed air, means for connecting the supply of gaseous fuel from the coal gas plant to the combustor, an oxygen plant for producing a supply of oxygen for use in the coal gas plant, the oxygen plant being of a type requiring a second supply of compressed air, means for diverting a portion of the first supply of compressed air equal to the second supply of compressed air and for connecting the portion to the oxygen plant, means for supplying a remainder of the first supply of compressed air to the combustor wherein the gaseous fuel is burned with the remainder of the first supply of compressed air, a heat recovery steam generator receiving an exhaust from the turbine and effective for generating a supply of steam, means for applying at least a portion of the steam for expansion in the turbine and the at least a portion of the steam having a mass flow rate sufficient to substantially compensate for the first supply of compressed air diverted from the air compressor whereby a total mass flow rate through the turbine is substantially equal to a total mass flow rate of the first supply of compressed air.

The above, and other objects, features and advantages of the present invention will become apparent from the following description read in conjunction with the accompanying drawings, in which like reference numerals designate the same elements.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a simplified block diagram of an integrated gas plant and combined cycle system according to the prior art.

FIG. 2 is a simplified block diagram of an integrated gas plant and combined cycle system according to an embodiment of the present invention.

DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENT

The present invention is directed toward a system having improved economics in producing a mechanical output. The mechanical output of the system described herein may be employed for driving any suitable process or for simultaneously driving a plurality of different processes with different ones of its mechanical outputs. If the outputs are used by different processes, the mechanical output of the system is the sum of the separate mechanical outputs. If the system is used to drive an electric generator, the gas turbine and steam turbine output shafts may be concentrically coupled to the generator shaft to produce a single electric output. The reduction in overall efficiency occasioned by the conversion from mechanical to electrical output is not of concern to the present invention. In an alternative embodiment, the mechanical output of the gas turbine may be employed to drive one process such as, for example, an electric generator, and the mechanical output of the steam turbine may be employed to drive a different equipment such a, for example, a second separate electric generator.

Referring to FIG. 1, there is shown, generally at 10, an integrated combined cycle system according to the prior art. A gas turbine 12 receives a gaseous fuel on a line 14 from a coal gas plant 16. Coal gas plant 16 receives a coal slurry on a coal slurry line 18. A conventional oxygen plant 20 receives a supply of compressed air from an air compressor 22 driven by an electric motor 24 and delivers a supply of substantially pure oxygen on a line 26 to coal gas plant 16. The gaseous fuel produced by coal gas plant 16 may be a coal gas of low heating content or the coal gas produced in coal gas plant 16 may be further reacted by known methods such as, for example, the Frischer Tropsch process, to produce a higher energy fuel gas such as, for example, methane. If integrated combined cycle system 10 is employed to generate electricity, a portion of the generated electricity may be used to drive electric motor 24. Otherwise, the electricity to drive electric motor 24 must be purchased. The amount of electric power consumed by electric motor 24 is about 8 megawatts for a small sized integrated combined cycle system 10 and thus represents a substantial economic penalty in reduced power output, if integrated combined cycle system 10 is employed to produce electric power, or in increased power cost, if the power must be purchased.

It is herein assumed that coal gas plant 16 and oxygen plant 20 are conventional and that the several processes and equipments therein are so well known to those skilled in the art that further description thereof would not add to the value of the disclosure herein. Further description of coal gas plant 16 and 20 is therefore omitted.

Gas turbine 12 includes an air compressor 28 which feeds compressed air at about 150 psig to a combustor 30. The fuel gas on line 14 is burned with the compressed air in combustor 30 to produce a rapidly flowing stream of a high-temperature mixture of products of combustion and excess air which is fed to a turbine 32. Turbine 32 includes vanes or buckets (not shown) therein which are impacted by the gas mixture to forcibly rotate an output shaft 34 which may be connected to any convenient load (not shown). A common shaft 36 couples a portion of the energy produced by turbine 32 to rotate air compressor 28.

An exhaust duct 38 from turbine 32 conveys a flow of exhaust products to a conventional heat recovery steam generator 40. The exhaust products on exhaust duct 38 are at a temperature of about 1030 degrees F. and therefore contain a substantial amount of heat energy which it is the task of heat recovery steam generator 40 to capture for further use. Heat recovery steam generator 40 conventionally contains a high pressure steam generator and superheater (not shown) for producing a supply of steam superheated to about 950 degrees F. for application to a high pressure steam turbine 42. Expansion of the steam in high pressure steam turbine 42 rotates an output shaft 44 which may be connected to a load (not shown). The steam exiting high pressure steam turbine 42 does so at a temperature of about 625 degrees F. and a pressure of about 200 psig and thus still contains a substantial amount of heat energy which may be further utilized.

Heat recovery steam generator 40 may contain a conventional reheater (not shown) which receives the spent steam from high pressure steam turbine 42 on a line 46, adds heat thereto, and delivers the reheated steam on a line 48 to an intermediate pressure turbine 50. Expansion of the steam in intermediate pressure turbine 50 rotates an output shaft 52 which may be connected to a load (not shown). Spent steam from intermediate pressure turbine 50 is connected on a line 54 to a condenser 56 wherein it is condensed to water for return on a return line 58 to heat recovery steam generator 40. A conventional cooling tower 60 may be provided for condensing the spent steam entering condenser 56. Make-up feedwater is added to heat recovery steam generator 40 on a make-up feedwater line 62. After having given up substantially all of its heat, the gas and steam exit heat recovery steam generator 40 on an exhaust conduit 64 at a temperature of about 280 degrees F. on its way to an exhaust stack (not shown).

In addition to the elements mentioned above, heat recovery steam generator 40 may additionally contain suitable economizers and additional evaporators (not shown) which are not of concern to the present invention.

Although output shafts 34, 44 and 52 are shown separated, these shafts may be concentrically connected together for concertedly driving a single load such as, for example, an electric generator (not shown).

Referring now to FIG. 2, there is shown, generally at 66 an integrated combined cycle system according to an embodiment of the invention in which elements corresponding to those identified in FIG. 1 are given the same reference designators. Slightly modified elements are given primed values of the same reference designators.

Air compressor 28' in gas turbine 12' includes a bleed line 68 which bleeds off a sufficient quantity of compressed air at an intermediate pressure of about 80 psig to satisfy the entire compressed air needs of oxygen plant 20. In the preferred embodiment of the invention, about 20 percent of the total air capacity of air compressor 28' is bled off through bleed line 68. With the entire compressed air needs of oxygen plant 20 satisfied, air compressor 22 and electric motor 24 of the prior art (FIG. 1) can be omitted. Omission of these elements eliminates their inherent energy inefficiencies as well.

It is, of course, economical and desirable to be able to employ conventional equipment without major redesign. Conventional gas turbines are designed as a unit in which the air and fuel mass flow rates in air compressor 28' and 30' are matched to the mass flow rate required for efficient operation of turbine 32. In the embodiment of the invention shown in FIG. 2, however, the mass flow rate of compressed air entering combustor 30' is reduced by the 20 percent bled off to reed oxygen plant 20. This reduced mass flow rate of compressed air is thus insufficient to satisfy the required mass flow rate of turbine 32 if a conventional gas turbine 12' is to be employed. Compensation for the reduced air mass flow rate is provided by a steam-injection conduit 70 which feeds spent steam from high pressure steam turbine 42 into combustor 30'. This spent steam is at a pressure of about 200 psig and a temperature of about 625 degrees F. and thus still contains a substantial amount of heat energy. Besides making up for the bled-off compressed air, the steam injected into combustor 30' provides other desirable effects. In particular, the injected steam is expanded in turbine 32 to recover part of its heat energy. The expanded steam exits turbine 32 on exhaust duct 38 with the same relatively high temperature as the remainder of the effluent of turbine 32. This remaining energy is substantially recovered in heat recovery steam generator 40' without the need for an intermediate pressure turbine 50 (FIG. 1). In addition to augmenting the mass flow rate through turbine 32 and recovering the heat energy in the spent steam from high pressure steam turbine 42, the injection of steam into combustor 30' also reduces the flame temperature within combustor 30' and thereby reduces the generation of NOx pollutants.

It fortuitously turns out that the mass flow rate of spent steam exiting high pressure steam turbine 42 is almost equal to the amount required to compensate for the mass flow rate of compressed air bled off by bleed line 68 to oxygen plant 20, considering the differences in mass per unit volume of air and steam. Under some operating conditions, it may be necessary or desirable to augment the steam from high pressure steam turbine 42. This is accomplished by providing an intermediate pressure steam conduit 72 from a conventional intermediate pressure evaporator (not shown) within heat recovery steam generator 40'. Steam in intermediate pressure steam conduit 72 adds to the steam in steam-injection conduit 70 for flow to combustor 30'.

A fuel gas heat exchanger 74 is optionally provided in line 14' for preheating the fuel gas from coal gas plant 16 to, for example, about 520 degrees F. before it is burned in combustor 30'. By reducing the amount of heat which must be added to the fuel gas before and during combustion, such preheating adds to the thermodynamic efficiency of gas turbine 12'. The heat for fuel gas heat exchanger 74 is obtained from high pressure saturated steam, or a mixture of water and saturated steam, at a temperature of about 600 degrees F. and a pressure of about 1600 psig, taken on a line 76 from a conventional high-pressure evaporator (not shown) in heat recovery steam generator 40'. While giving up its heat to the fuel gas in fuel gas heat exchanger 74, substantially all of the steam is converted to water at about atmospheric pressure and a temperature of about 280 degrees F. The water from fuel gas heat exchanger 74 is fed on a line 78 to a de-aerator 80.

Coal gas plant 16 is conventionally of a type which generates a quantity of low-pressure process steam. At least a portion of such process steam may be applied on a line 82 to de-aerator 80. If an excess of process steam is available from coal gas plant 16, it may optionally be conveyed on a line 84 to external using processes (not shown) which are not of concern to the present disclosure.

A supply of make-up feedwater is applied to de-aerator 80 on a make-up feedwater line 86. A feedwater pump 88 returns the de-aerated feedwater from de-aerator 80 to heat recovery steam generator 40'.

As a result of the steam released from high pressure steam turbine 42 to the atmosphere by expansion in turbine 32 and of the cooling of high pressure steam in fuel gas heat exchanger 74, operation of integrated combined cycle system 66 is enabled without the use of a condenser 56 or a cooling tower 60 (FIG. 1). In addition, since the heat energy in the intermediate pressure steam exiting high pressure steam turbine 42 is recaptured by expansion in turbine 32 and absorption in heat recovery steam generator 40', the need for intermediate pressure turbine 50 (FIG. 1) is eliminated. One skilled in the art would immediately recognize the large capital cost reduction obtainable by eliminating intermediate pressure turbine 50, condenser 56 and cooling tower 60. In addition, the elimination of intermediate pressure turbine 50 and the substitution of the more efficient process of expansion in turbine 32, followed by additional heat recovery in heat recovery steam generator 40', increases the efficiency of integrated combined cycle system 66 of FIG. 2 over integrated combined cycle system 10 of FIG. 1. In accordance with the common engineering principal that a large unit is more efficient than a smaller unit, it is reasonable to assume that the efficiency of air compressor 28' is greater than the efficiency of air compressor 22 (FIG. 1), the need for which is eliminated by the present invention. In addition, by eliminating electric motor 24 (FIG. 1) and directly producing compressed air, rather than first producing or buying electricity, and then consuming the electricity in electric motor 24, both of which processes are far less than 100 percent efficient, two of the intermediate inefficiencies of the three-step process of producing electricity; namely, the electric generation and consumption, are eliminated, and the remaining process of air compression is performed in an apparatus which may be more efficient than the air compression apparatus employed in the prior art.

As is well known by one skilled in the art, the temperature of the exhaust products entering heat recovery steam generator 40' is lower than is desirable from the strict point of view of capturing the maximum amount of heat energy from the exhaust products. Temperatures of several hundred degrees higher than the 1030 degrees F. are generally preferred. In order to accomplish an increase in the heat transfer in heat recovery steam generator 40', and/or to increase the amount of steam generated in heat recovery steam generator 40', an auxiliary source of heat may be applied such as, for example, by applying a liquid or gaseous fuel to heat recovery steam generator 40' on a fuel line 90 for burning therein in a conventional burner (not shown).

Although output shafts 34 and 44 are shown as separate elements which may be connected to different loads, one conventional application employs concentric output shafts 34 and 44 on a single using process such as, for example, an electric generator.

Having described preferred embodiments of the invention with reference to the accompanying drawings, it is to be understood that the invention is not limited to those precise embodiments, and that various changes and modifications may be effected therein by one skilled in the art without departing from the scope or spirit of the invention as defined in the appended claims.

Claims (3)

What is claimed is:
1. An improved integrated coal gas and combined cycle plant including;
a coal gas plant for producing gaseous fuel; an oxygen plant for supplying oxygen to said coal gas plant, a gas turbine plant producing a hot exhaust gas, a heat recovery steam generator receiving said hot exhaust gas and for producing a steam output, a non-condensing steam turbine for receiving said steam generator output; and, wherein the improvement comprises;
means for a portion of the gas turbine plant compressed air to the oxygen plant;
means for delivering substantially all of the steam turbine exhaust to the gas turbine plant combustor whereby the mass flow rate through the gas turbine plant remains substantially constant; and,
a high pressure steam tap from said heat recovery steam generator to a gaseous fuel preheater whereby substantially all of the high pressure steam is converted back to feedwater.
2. The improved plant recited in claim 1 wherein the improvement further comprises:
an intermediate pressure steam tap from said heat recovery steam generator to said steam turbine exhaust delivery means for selectively augmenting the steam supply to said gas turbine plant.
3. An integrated coal gasification and combined cycle power plant comprising:
a coal gasification plant for producing coal gas;
an oxygen plant for producing oxygen for the coal gasification plant;
a combined cycle plant including a steam turbine, a heat recovery steam generator and a gas turbine plant; the gas turbine plant receiving coal gas from the coal gasification plant and including an air compressor, a combustor and a gas turbine;
means for delivering at least a portion of the steam turbine exhaust to the gas turbine plant to replace the diverted air portion whereby the mass flow through the gas turbine plant remains constant;
means for tapping off unexpanded steam from the heat recovery steam generator to augment the flow of steam to the gas turbine plant; and,
means for heating the coal gas delivered to the gas turbine plant including heat exchange means connected to a second steam tap on the heat recovery steam generator.
means for diverting a portion of the gas turbine plant compressor air to the oxygen plant;
US06/854,370 1984-12-03 1986-04-21 Integrated coal gasification plant and combined cycle system with air bleed and steam injection Expired - Lifetime US4785622A (en)

Priority Applications (2)

Application Number Priority Date Filing Date Title
US67737584A true 1984-12-03 1984-12-03
US06/854,370 US4785622A (en) 1984-12-03 1986-04-21 Integrated coal gasification plant and combined cycle system with air bleed and steam injection

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
US06/854,370 US4785622A (en) 1984-12-03 1986-04-21 Integrated coal gasification plant and combined cycle system with air bleed and steam injection

Related Parent Applications (1)

Application Number Title Priority Date Filing Date
US67737584A Continuation 1984-12-03 1984-12-03

Publications (1)

Publication Number Publication Date
US4785622A true US4785622A (en) 1988-11-22

Family

ID=27101773

Family Applications (1)

Application Number Title Priority Date Filing Date
US06/854,370 Expired - Lifetime US4785622A (en) 1984-12-03 1986-04-21 Integrated coal gasification plant and combined cycle system with air bleed and steam injection

Country Status (1)

Country Link
US (1) US4785622A (en)

Cited By (47)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4932204A (en) * 1989-04-03 1990-06-12 Westinghouse Electric Corp. Efficiency combined cycle power plant
WO1991015665A1 (en) * 1990-04-03 1991-10-17 A. Ahlstrom Corporation Method and apparatus for generating heat and electricity in a sulphate pulp mill
US5218815A (en) * 1991-06-04 1993-06-15 Donlee Technologies, Inc. Method and apparatus for gas turbine operation using solid fuel
US5241816A (en) * 1991-12-09 1993-09-07 Praxair Technology, Inc. Gas turbine steam addition
US5261225A (en) * 1985-12-26 1993-11-16 Dipac Associates Pressurized wet combustion at increased temperature
US5265410A (en) * 1990-04-18 1993-11-30 Mitsubishi Jukogyo Kabushiki Kaisha Power generation system
US5357746A (en) * 1993-12-22 1994-10-25 Westinghouse Electric Corporation System for recovering waste heat
US5379589A (en) * 1991-06-17 1995-01-10 Electric Power Research Institute, Inc. Power plant utilizing compressed air energy storage and saturation
US5495709A (en) * 1994-08-05 1996-03-05 Abb Management Ag Air reservoir turbine
US5564269A (en) * 1994-04-08 1996-10-15 Westinghouse Electric Corporation Steam injected gas turbine system with topping steam turbine
US5572861A (en) * 1995-04-12 1996-11-12 Shao; Yulin S cycle electric power system
US5595059A (en) * 1995-03-02 1997-01-21 Westingthouse Electric Corporation Combined cycle power plant with thermochemical recuperation and flue gas recirculation
US5623822A (en) * 1995-05-23 1997-04-29 Montenay International Corp. Method of operating a waste-to-energy plant having a waste boiler and gas turbine cycle
US5628183A (en) * 1994-10-12 1997-05-13 Rice; Ivan G. Split stream boiler for combined cycle power plants
US5664414A (en) * 1995-08-31 1997-09-09 Ormat Industries Ltd. Method of and apparatus for generating power
US5715671A (en) * 1991-03-11 1998-02-10 Jacobs Engineering Limited Clean power generation using IGCC process
US6041588A (en) * 1995-04-03 2000-03-28 Siemens Aktiengesellschaft Gas and steam turbine system and operating method
US6089024A (en) * 1998-11-25 2000-07-18 Elson Corporation Steam-augmented gas turbine
AU741118B2 (en) * 1997-06-06 2001-11-22 Texaco Development Corporation Air extraction in a gasification process
US6389793B1 (en) 2000-04-19 2002-05-21 General Electric Company Combustion turbine cooling media supply system and related method
US6405521B1 (en) 2001-05-23 2002-06-18 General Electric Company Gas turbine power augmentation injection system and related method
US6430915B1 (en) 2000-08-31 2002-08-13 Siemens Westinghouse Power Corporation Flow balanced gas turbine power plant
US6446440B1 (en) 2000-09-15 2002-09-10 General Electric Company Steam injection and inlet fogging in a gas turbine power cycle and related method
WO2003001046A2 (en) * 2001-06-21 2003-01-03 Alstom Technology Ltd Method for operating an internal combustion engine
US6553768B1 (en) 2000-11-01 2003-04-29 General Electric Company Combined water-wash and wet-compression system for a gas turbine compressor and related method
WO2003069132A1 (en) 2002-02-11 2003-08-21 L'air Liquide, Societe Anonyme A Directoire Et Conseil De Surveillance Pour L'etude Et L'exploitation Des Procedes Georges Claude Integrated air separation and oxygen fired power generation system
US6735490B2 (en) 2001-10-12 2004-05-11 General Electric Company Method and system for automated integration of design analysis subprocesses
US20050223728A1 (en) * 2002-03-28 2005-10-13 Franz Stuhlmueller Refrigerator power plant
US20060042259A1 (en) * 2004-08-31 2006-03-02 Shinya Marushima Combined-cycle power plant and steam thermal power plant
US20070033942A1 (en) * 2005-08-10 2007-02-15 Eribert Benz Method for operating a gas turbine and a gas turbine for implementing the method
WO2007017490A1 (en) * 2005-08-10 2007-02-15 Alstom Technology Ltd Method for operating a gas turbine, and gas turbine for carrying out the method
US20070033943A1 (en) * 2005-08-10 2007-02-15 Eribert Benz Method for operating a gas turbine as well as a gas turbine for implementing the method
US20070033918A1 (en) * 2005-08-10 2007-02-15 Eribert Benz Method for operating a gas turbine and a gas turbine for implementing the method
WO2007017487A1 (en) * 2005-08-10 2007-02-15 Alstom Technology Ltd Method for operating a gas turbine, and gas turbine for carrying out the method
US20070039468A1 (en) * 2005-08-10 2007-02-22 Eribert Benz Method for operating a gas turbine and a gas turbine for implementing the method
US20070256422A1 (en) * 2006-05-08 2007-11-08 Econo-Power International Corporation Production enhancements on integrated gasification combined cycle power plants
US20080060521A1 (en) * 2006-09-07 2008-03-13 Terry Hughes Methods and apparatus for reducing emissions in an integrated gasification combined cycle
WO2008065156A1 (en) * 2006-12-01 2008-06-05 Alstom Technology Ltd Method for operating a gas turbine
US20090301099A1 (en) * 2006-06-23 2009-12-10 Nello Nigro Power Generation
US20100251729A1 (en) * 2007-01-04 2010-10-07 Siemens Power Generation, Inc. Power generation system incorporating multiple Rankine cycles
US20100264655A1 (en) * 2009-04-15 2010-10-21 General Electric Company Systems involving multi-spool generators
EP2253807A1 (en) * 2008-10-29 2010-11-24 Vítkovice Power Engineering a.s. Gas turbine cycle or combined steam-gas cycle for production of power from solid fuels and waste heat
US20130104562A1 (en) * 2010-07-02 2013-05-02 Russell H. Oelfke Low Emission Tripe-Cycle Power Generation Systems and Methods
US20130252314A1 (en) * 2010-12-09 2013-09-26 Weifang Jinsida Industrial Co. Ltd. Resource utilizing method of refuses in urban and rural
US20140150443A1 (en) * 2012-12-04 2014-06-05 General Electric Company Gas Turbine Engine with Integrated Bottoming Cycle System
CZ305777B6 (en) * 2014-12-19 2016-03-09 VĂŤTKOVICE POWER ENGINEERING a.s. Temperature control method upstream a gas turbine engine and apparatus for making the same
EP2661549B1 (en) * 2011-01-05 2017-05-10 Duerr Cyplan Ltd. Device for generating energy

Citations (11)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2959005A (en) * 1958-06-04 1960-11-08 Bbc Brown Boveri & Cie Gas turbine plant and method of operating the same
US3703807A (en) * 1971-01-15 1972-11-28 Laval Turbine Combined gas-steam turbine power plant
US3832845A (en) * 1972-09-07 1974-09-03 Sulzer Ag Combined gas and steam powerplant with supplementary steam mixing
US3930367A (en) * 1974-10-23 1976-01-06 General Electric Company Fluid flow control system
SU523998A1 (en) * 1975-03-03 1976-08-05 Ленинградский Ордена Ленина Политехнический Институт Им.М.И.Калинина combined cycle power plant
JPS5268608A (en) * 1975-12-05 1977-06-07 Babcock Hitachi Kk Power generator
US4058974A (en) * 1975-05-14 1977-11-22 Bbc Brown Boveri & Company Limited Combined gas/steam power plant with pressurized-gas generator
JPS5535108A (en) * 1978-09-01 1980-03-12 Hitachi Ltd Controlling system for gas turbine steam jet system of combined cycle generator plant
JPS5954736A (en) * 1982-09-22 1984-03-29 Mitsubishi Heavy Ind Ltd Combined power generation system through fuel cracking
US4472936A (en) * 1980-12-27 1984-09-25 Hitachi, Ltd. Method and apparatus for controlling combustion of gasified fuel
US4488398A (en) * 1981-11-09 1984-12-18 Hitachi, Ltd. Power plant integrated with coal gasification

Patent Citations (11)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2959005A (en) * 1958-06-04 1960-11-08 Bbc Brown Boveri & Cie Gas turbine plant and method of operating the same
US3703807A (en) * 1971-01-15 1972-11-28 Laval Turbine Combined gas-steam turbine power plant
US3832845A (en) * 1972-09-07 1974-09-03 Sulzer Ag Combined gas and steam powerplant with supplementary steam mixing
US3930367A (en) * 1974-10-23 1976-01-06 General Electric Company Fluid flow control system
SU523998A1 (en) * 1975-03-03 1976-08-05 Ленинградский Ордена Ленина Политехнический Институт Им.М.И.Калинина combined cycle power plant
US4058974A (en) * 1975-05-14 1977-11-22 Bbc Brown Boveri & Company Limited Combined gas/steam power plant with pressurized-gas generator
JPS5268608A (en) * 1975-12-05 1977-06-07 Babcock Hitachi Kk Power generator
JPS5535108A (en) * 1978-09-01 1980-03-12 Hitachi Ltd Controlling system for gas turbine steam jet system of combined cycle generator plant
US4472936A (en) * 1980-12-27 1984-09-25 Hitachi, Ltd. Method and apparatus for controlling combustion of gasified fuel
US4488398A (en) * 1981-11-09 1984-12-18 Hitachi, Ltd. Power plant integrated with coal gasification
JPS5954736A (en) * 1982-09-22 1984-03-29 Mitsubishi Heavy Ind Ltd Combined power generation system through fuel cracking

Cited By (80)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5261225A (en) * 1985-12-26 1993-11-16 Dipac Associates Pressurized wet combustion at increased temperature
JPH02283803A (en) * 1989-04-03 1990-11-21 Westinghouse Electric Corp <We> Combined cycle power plant running method and combined cycle power plant
US4932204A (en) * 1989-04-03 1990-06-12 Westinghouse Electric Corp. Efficiency combined cycle power plant
WO1991015665A1 (en) * 1990-04-03 1991-10-17 A. Ahlstrom Corporation Method and apparatus for generating heat and electricity in a sulphate pulp mill
US5370772A (en) * 1990-04-03 1994-12-06 A. Ahlstrom Corporation Method for generating heat and electricity in a sulphate pulp mill
AU652360B2 (en) * 1990-04-03 1994-08-25 A. Ahlstrom Corporation Method and apparatus for generating heat and electricity in a sulphate pulp mill
US5265410A (en) * 1990-04-18 1993-11-30 Mitsubishi Jukogyo Kabushiki Kaisha Power generation system
US5715671A (en) * 1991-03-11 1998-02-10 Jacobs Engineering Limited Clean power generation using IGCC process
US5218815A (en) * 1991-06-04 1993-06-15 Donlee Technologies, Inc. Method and apparatus for gas turbine operation using solid fuel
US5379589A (en) * 1991-06-17 1995-01-10 Electric Power Research Institute, Inc. Power plant utilizing compressed air energy storage and saturation
US5241816A (en) * 1991-12-09 1993-09-07 Praxair Technology, Inc. Gas turbine steam addition
US5357746A (en) * 1993-12-22 1994-10-25 Westinghouse Electric Corporation System for recovering waste heat
US5564269A (en) * 1994-04-08 1996-10-15 Westinghouse Electric Corporation Steam injected gas turbine system with topping steam turbine
US5495709A (en) * 1994-08-05 1996-03-05 Abb Management Ag Air reservoir turbine
US5628183A (en) * 1994-10-12 1997-05-13 Rice; Ivan G. Split stream boiler for combined cycle power plants
US5595059A (en) * 1995-03-02 1997-01-21 Westingthouse Electric Corporation Combined cycle power plant with thermochemical recuperation and flue gas recirculation
US6041588A (en) * 1995-04-03 2000-03-28 Siemens Aktiengesellschaft Gas and steam turbine system and operating method
US5664411A (en) * 1995-04-12 1997-09-09 Shao; Yulin S cycle electric power system
US5572861A (en) * 1995-04-12 1996-11-12 Shao; Yulin S cycle electric power system
US5623822A (en) * 1995-05-23 1997-04-29 Montenay International Corp. Method of operating a waste-to-energy plant having a waste boiler and gas turbine cycle
US5724807A (en) * 1995-05-23 1998-03-10 Montenay International Corp. Combined gas turbine-steam cycle waste-to-energy plant
US5664414A (en) * 1995-08-31 1997-09-09 Ormat Industries Ltd. Method of and apparatus for generating power
AU741118B2 (en) * 1997-06-06 2001-11-22 Texaco Development Corporation Air extraction in a gasification process
US6089024A (en) * 1998-11-25 2000-07-18 Elson Corporation Steam-augmented gas turbine
US6389793B1 (en) 2000-04-19 2002-05-21 General Electric Company Combustion turbine cooling media supply system and related method
US6584779B2 (en) 2000-04-19 2003-07-01 General Electric Company Combustion turbine cooling media supply method
US6481212B2 (en) 2000-04-19 2002-11-19 General Electric Company Combustion turbine cooling media supply system and related method
US6430915B1 (en) 2000-08-31 2002-08-13 Siemens Westinghouse Power Corporation Flow balanced gas turbine power plant
US6446440B1 (en) 2000-09-15 2002-09-10 General Electric Company Steam injection and inlet fogging in a gas turbine power cycle and related method
US6553768B1 (en) 2000-11-01 2003-04-29 General Electric Company Combined water-wash and wet-compression system for a gas turbine compressor and related method
US6405521B1 (en) 2001-05-23 2002-06-18 General Electric Company Gas turbine power augmentation injection system and related method
US20040182330A1 (en) * 2001-06-21 2004-09-23 Frutschi Hans Ulrich Method for operating an internal combustion engine
WO2003001046A3 (en) * 2001-06-21 2003-03-13 Alstom Switzerland Ltd Method for operating an internal combustion engine
WO2003001046A2 (en) * 2001-06-21 2003-01-03 Alstom Technology Ltd Method for operating an internal combustion engine
US6845738B2 (en) 2001-06-21 2005-01-25 Alstom Technology Ltd Method for operating an internal combustion engine
US6735490B2 (en) 2001-10-12 2004-05-11 General Electric Company Method and system for automated integration of design analysis subprocesses
US7284362B2 (en) 2002-02-11 2007-10-23 L'Air Liquide, Société Anonyme à Directoire et Conseil de Surveillance pour l'Étude et l'Exploitation des Procedes Georges Claude Integrated air separation and oxygen fired power generation system
US20040016237A1 (en) * 2002-02-11 2004-01-29 Ovidiu Marin Integrated air separation and oxygen fired power generation system
WO2003069132A1 (en) 2002-02-11 2003-08-21 L'air Liquide, Societe Anonyme A Directoire Et Conseil De Surveillance Pour L'etude Et L'exploitation Des Procedes Georges Claude Integrated air separation and oxygen fired power generation system
US20050223728A1 (en) * 2002-03-28 2005-10-13 Franz Stuhlmueller Refrigerator power plant
US7178348B2 (en) * 2002-03-28 2007-02-20 Siemens Aktiengesellschaft Refrigeration power plant
US20060042259A1 (en) * 2004-08-31 2006-03-02 Shinya Marushima Combined-cycle power plant and steam thermal power plant
US20080289337A1 (en) * 2004-08-31 2008-11-27 Shinya Marushima Combined-cycle power plant and steam thermal power plant
US20080289316A1 (en) * 2004-08-31 2008-11-27 Shinya Marushima Combined-cycle power plant and steam thermal power plant
WO2007017487A1 (en) * 2005-08-10 2007-02-15 Alstom Technology Ltd Method for operating a gas turbine, and gas turbine for carrying out the method
US20070033918A1 (en) * 2005-08-10 2007-02-15 Eribert Benz Method for operating a gas turbine and a gas turbine for implementing the method
US20070039468A1 (en) * 2005-08-10 2007-02-22 Eribert Benz Method for operating a gas turbine and a gas turbine for implementing the method
US20070033943A1 (en) * 2005-08-10 2007-02-15 Eribert Benz Method for operating a gas turbine as well as a gas turbine for implementing the method
CN101238341B (en) 2005-08-10 2012-04-18 阿尔斯托姆科技有限公司 Method for operating a gas turbine and a gas turbine for implementing the method
US7584598B2 (en) 2005-08-10 2009-09-08 Alstom Technology Ltd. Method for operating a gas turbine and a gas turbine for implementing the method
US7584599B2 (en) 2005-08-10 2009-09-08 Alstom Technology Ltd. Method for operating a gas turbine as well as a gas turbine for implementing the method
US7574855B2 (en) 2005-08-10 2009-08-18 Alstom Technology Ltd. Method for operating a gas turbine and a gas turbine for implementing the method
US7513118B2 (en) 2005-08-10 2009-04-07 Alstom Technology Ltd. Method for operating a gas turbine and a gas turbine for implementing the method
WO2007017490A1 (en) * 2005-08-10 2007-02-15 Alstom Technology Ltd Method for operating a gas turbine, and gas turbine for carrying out the method
US20070033942A1 (en) * 2005-08-10 2007-02-15 Eribert Benz Method for operating a gas turbine and a gas turbine for implementing the method
US7451591B2 (en) * 2006-05-08 2008-11-18 Econo-Power International Corporation Production enhancements on integrated gasification combined cycle power plants
US20070256422A1 (en) * 2006-05-08 2007-11-08 Econo-Power International Corporation Production enhancements on integrated gasification combined cycle power plants
US20090301099A1 (en) * 2006-06-23 2009-12-10 Nello Nigro Power Generation
US20080060521A1 (en) * 2006-09-07 2008-03-13 Terry Hughes Methods and apparatus for reducing emissions in an integrated gasification combined cycle
US8038779B2 (en) 2006-09-07 2011-10-18 General Electric Company Methods and apparatus for reducing emissions in an integrated gasification combined cycle
US20090260368A1 (en) * 2006-12-01 2009-10-22 Eribert Benz Method for operating a gas turbine
US8375723B2 (en) * 2006-12-01 2013-02-19 Alstom Technology Ltd. Method for operating a gas turbine
JP2010511123A (en) * 2006-12-01 2010-04-08 アルストム テクノロジー リミテッドALSTOM Technology Ltd Method of operating a gas turbine
WO2008065156A1 (en) * 2006-12-01 2008-06-05 Alstom Technology Ltd Method for operating a gas turbine
US20100251729A1 (en) * 2007-01-04 2010-10-07 Siemens Power Generation, Inc. Power generation system incorporating multiple Rankine cycles
US7934383B2 (en) * 2007-01-04 2011-05-03 Siemens Energy, Inc. Power generation system incorporating multiple Rankine cycles
US20110203289A1 (en) * 2007-01-04 2011-08-25 Gutierrez Juan P Power generation system incorporating multiple rankine cycles
US8371099B2 (en) * 2007-01-04 2013-02-12 Siemens Energy, Inc. Power generation system incorporating multiple Rankine cycles
EP2253807A1 (en) * 2008-10-29 2010-11-24 Vítkovice Power Engineering a.s. Gas turbine cycle or combined steam-gas cycle for production of power from solid fuels and waste heat
CN101915128A (en) * 2009-04-15 2010-12-15 通用电气公司 System comprising multiple spool generators
US20100264655A1 (en) * 2009-04-15 2010-10-21 General Electric Company Systems involving multi-spool generators
CN101915128B (en) 2009-04-15 2013-06-19 通用电气公司 System comprising multiple spool generators
US8164208B2 (en) * 2009-04-15 2012-04-24 General Electric Company Systems involving multi-spool generators and variable speed electrical generators
US20130104562A1 (en) * 2010-07-02 2013-05-02 Russell H. Oelfke Low Emission Tripe-Cycle Power Generation Systems and Methods
US9776224B2 (en) * 2010-12-09 2017-10-03 Weifang Jinsida Industrial Co. Ltd. Method of utilizing refuses in urban and rural
US20130252314A1 (en) * 2010-12-09 2013-09-26 Weifang Jinsida Industrial Co. Ltd. Resource utilizing method of refuses in urban and rural
EP2661549B1 (en) * 2011-01-05 2017-05-10 Duerr Cyplan Ltd. Device for generating energy
US20140150443A1 (en) * 2012-12-04 2014-06-05 General Electric Company Gas Turbine Engine with Integrated Bottoming Cycle System
US9410451B2 (en) * 2012-12-04 2016-08-09 General Electric Company Gas turbine engine with integrated bottoming cycle system
CZ305777B6 (en) * 2014-12-19 2016-03-09 VĂŤTKOVICE POWER ENGINEERING a.s. Temperature control method upstream a gas turbine engine and apparatus for making the same

Similar Documents

Publication Publication Date Title
SU1452490A3 (en) Half-peak-load power station
US7284362B2 (en) Integrated air separation and oxygen fired power generation system
KR100818830B1 (en) Compressor discharge bleed air circuit in gas turbine plants and related method
US5953899A (en) Integrated drying of feedstock feed to integrated combined-cycle gasification plant
US5388395A (en) Use of nitrogen from an air separation unit as gas turbine air compressor feed refrigerant to improve power output
US5865023A (en) Gasification combined cycle power generation process with heat-integrated chemical production
EP0589960B1 (en) Power plant utilizing compressed air energy storage
US5970702A (en) Reduced pollution hydrocarbon combustion gas generator
US4193259A (en) Process for the generation of power from carbonaceous fuels with minimal atmospheric pollution
US5507141A (en) Process for recovering energy from a combustible gas
CN1020348C (en) Electric power generation method of binding gasify combination cycle
US6430915B1 (en) Flow balanced gas turbine power plant
AU668781B2 (en) Combined combustion and steam turbine power plant
US5495709A (en) Air reservoir turbine
JP3142565B2 (en) Improved clean power generation device
US6321539B1 (en) Retrofit equipment for reducing the consumption of fossil fuel by a power plant using solar insolation
AU754398B2 (en) Method of generating power using an advanced thermochemical recuperation cycle
US6945052B2 (en) Methods and apparatus for starting up emission-free gas-turbine power stations
US4116005A (en) Combined cycle power plant with atmospheric fluidized bed combustor
US4282708A (en) Method for the shutdown and restarting of combined power plant
US5704209A (en) Externally fired combined cycle gas turbine system
US4697415A (en) Combined gas and steam-turbine power generating station
US6397575B2 (en) Apparatus and methods of reheating gas turbine cooling steam and high pressure steam turbine exhaust in a combined cycle power generating system
CA1126029A (en) Process for the generation of power from solid carbonaceous fuels
US4831817A (en) Combined gas-steam-turbine power plant

Legal Events

Date Code Title Description
REMI Maintenance fee reminder mailed
REIN Reinstatement after maintenance fee payment confirmed
FP Expired due to failure to pay maintenance fee

Effective date: 19921122

SULP Surcharge for late payment
FPAY Fee payment

Year of fee payment: 4

STCF Information on status: patent grant

Free format text: PATENTED CASE

DP Notification of acceptance of delayed payment of maintenance fee